Distrigas of Massachusetts Corporation

First Revised Volume No. 1

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Effective Date: 09/01/1995, Docket: RP95-400-002, Status: Effective

Substitute First Revised Sheet No. 79 Substitute First Revised Sheet No. 79 : Superseded

Superseding: FIRST REVISED SHEET NO. 79

RATE SCHEDULE FLSS

(continued)

Buyer and Seller may negotiate an agreement whereby

Seller will agree to fill Buyer's facilities to

their capacity ("Liquid Storage Capacity") on or

before November 15 (or other mutually agreed date)

and to keep Buyer's facilities filled to a negotiated

level of Buyer's Liquid Storage Capacity ("Daily

Minimum Storage Quantity") during the peak shaving

period (November 15 until March 15) to be negotiated

with each buyer. Buyer and Seller may negotiate an

agreement to keep the volume of liquid between the

Daily Minimum Storage Quantity and a mutually agreed

maximum quantity ("Daily Maximum Storage Quantity") for

the service period established for each customer.

2.6 Vapor Option. Buyer and Seller may negotiate a

vapor option under which, at Buyer's request, Seller

shall on any given day attempt to deliver the LNG

purchased by Buyer as vapor on an interruptible

basis. The availability of the interruptible vapor

option and related volumes shall be determined in

Seller's sole discretion and judgment.

2.7 Excess Volumes. Seller, in its sole discretion and

judgment, may make volumes in excess of MDQ available

to Buyer on a daily basis.

3.0 Rate.

3.1 Call Payment. (a) A prepayment ("Call Payment") may

be required in an amount to be negotiated between

Buyer and Seller. As to sales hereunder for resale

in interstate commerce, the Call Payment negotiated

between Buyer and Seller will not exceed, on a unit

basis, the Call Payment Cap. The Call Payment Cap

shall be the sum of the firm transportation demand

charges associated with the transportation of gas from

western Canada to Buyer, consisting of: (i) the

demand charges under NOVA's Rate Schedule FS for

firm transportation within Alberta to a point of

interconnection with TransCanada Pipeline Ltd.

("TransCanada") at Empress, Alberta; (ii) the demand

charges under TransCanada's FS Toll Schedule for

firm transportation from Empress to the U.S.-

Canadian border at Iroquois, Ontario; (iii) the

demand charges under Iroquois Gas Transmission Co.,

L.P.'s ("Iroquois") Rate Schedule RTS-1 for firm

transportation from the border to Wright, N.Y.; and

(iv) the demand charges for firm transportation from

Wright, N.Y. to Buyer under Tennessee Gas Pipeline

Company's ("Tennessee") Rate Schedule NET or Algonquin

Gas Transmission Company's ("Algonquin") Rate Schedule

AFT-2, or, if Buyer is not currently served by Canadian

supplies delivered through the Iroquois system, then

the demand charge component of this Subsection 3.1 (a)

(iv) shall be the demand charges under Tennessee's Rate

Schedule NET for firm transportation from Wright, N.Y.

to eastern Massachusetts.